HomeMy WebLinkAbout20060706IPC to Staff 19-24, 28, 47, 72.pdfiSiI IDAHO POWER COMPANY
O. BOX 70
BOISE, IDAHO 83707
July 6, 2006
~~b" t; QUNE
Senior Attorney
2006 JUL -6 PH 3: 32
IDAHO PUBLIC
UTiliTIES COMMISSION
An IDACORP Company
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P. O. Box 83720
Boise , Idaho 83720-0074
Re:Case No. IPC-06-
Idaho Power Company s Response to the First Production
Request of Commission Staff
Dear Ms. Jewell:
Please find enclosed for filing an original and two (2) copies of Idaho Power
Company s Response to the First Production Request of Commission Staff regarding
the above-described case.
I would appreciate it if you would return a stamped copy of this transmittal letter
to me in the enclosed self-addressed stamped envelope.
Very truly yours
C~idJcL-Barton L. Kline
BLK:sh
Enclosures
Telephone (208) 388-2682 Fax (208) 388-6936, E-mail BKline(g)idahopower.com
ic'
BARTON L. KLINE ISB #1526
MONICA B. MOEN ISB #5734
Idaho Power Company
O. Box 70
Boise, Idaho 83707
Telephone: (208) 388-2682
FAX Telephone: (208) 388-6936
REceIVED
2006 JUl-6 PM 3: 32
IDAHO PU8L1CUTILITIES COMMISSION
Attorney for Idaho Power Company
Street Address for Express Mail
1221 West Idaho Street
Boise , Idaho 83702
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR A
CERTIFICATE OF PUBLIC CONVENIENCE)
AND NECESSITY FOR THE RATE BASING
OF THE EV ANDER ANDREWS POWERPLANT.
CASE NO. IPC-06-
IDAHO POWER COMPANY'
RESPONSE TO THE FIRST
PRODUCTION REQUEST OF
COMMISSION STAFF
COMES NOW, Idaho Power Company ("Idaho Power" or "the Company
and in response to the First Production Request of the Commission Staff to Idaho Power
Company dated June 16, 2006, herewith submits the following information:
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page
REQUEST NO. 19: Please describe any transmission system additions or
improvements , including cost , which will be needed to interconnect the Evander
Andrews plant into Idaho Power s existing system.
RESPONSE TO REQUEST NO. 19:
$ 4.6 Million - Bennett Mountain to Evander Andrews 230 kV line and
substation terminals
$17.8 Million - Evander Andrews to Mora 230 kV line and substation
improvements
$ 0.4 Million - 230 kV generator connection terminal at Evander Andrews
Substation
The response to this request was prepared by Roger Grim , Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 2
REQUEST NO. 20: Please describe any permits that will be required for
transmission system additions or improvements and provide time estimates of when
such permits could be obtained. If any permits will be required , what is their status?
RESPONSE TO REQUEST NO. 20:
The following activities are required prior to receiving right of way(ROW)
permission to cross BLM land.
Environmental Assessment - currently being written
Candidate Conservation Agreement (may be required) - currently being
assessed/writte n
Biological Assessment (may be required) - currently being
assessed/written
State Historic Preservation Office (SHPO) - cultural resource survey
performed in 2005. Small addition to route done in 2006. Consultation
with SHPO following completion of technical report.
A Conditional Use permit must be issued from Ada County.
A Conditional Use permit may be required from Elmore County (none was
required for the Bennett Mountain to Rattlesnake line).
Idaho Power will check with Bureau of Reclamation to see if they will accept
documents prepared for the BLM for their ROW process.
Idaho Power will check with State Lands to see if they need additional
information for ROW.
None of these requirements are presently anticipated to delay the completion
of the transmission improvements.
The response to this request was prepared by Roger Grim , Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 3
REQUEST NO. 21: Please describe any transmission system additions or
improvements, including cost and construction timing, which will be needed between
Mountain Home and Boise in order to accommodate the Evander Andrews Plant. Are
there any improvements being made in the general vicinity of the Evander Andrews
plant that Idaho Power would have made whether the Evander Andrews plant was built
or not?
RESPONSE TO REQUEST NO. 21:
$ 4.6 Million - In-service Winter 2007 - Bennett Mountain to Evander
Andrews 230 kV line and substation terminals
$17.8 Million - In-service Spring 2008 - Evander Andrews to Mora 230 kV
line and substation improvements
$ 0.4 Million - In-service Winter 2007 - 230 kV generator connection
terminal at Evander Andrews Substation
Operational concerns presently exist between the Mountain Home area
and Boise. While no commitment had been made for transmission system
improvements to address the operational concerns prior to this generator
interconnection process, Idaho Power now intends to make two additional transmission
improvements in the same timeframe as the transmission improvements needed to
interconnect Evander Andrews generation. These are: (1) a 230/138 kV transformer at
Evander Andrews and (2) the re-conductor of the Evander Andrews/Mountain Home
Junction 138 kv transmission line. These improvements are proposed to alleviate the
above-referenced operational concerns. These transmission improvements are
estimated to cost approximately $4 million. The combination of the $22.8 million to
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 4
interconnect the generator and the additional $4 million to address existing operational
concerns , compliment each other and accomplish both objectives.
The response to this request was prepared by Roger Grim, Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 5
REQUEST NO. 22: Please describe the transmission constraints that
made it desirable or necessary for Idaho Power to specify in the March 2005 RFP that
Idaho Power is interested in proposals that can provide electric capacity to the Treasure
Valley load center. Provide copies of any analysis or transmission system studies in
which these constraints were identified-and described.
RESPONSE TO REQUEST NO. 22:
The following transmission constraints are either fully subscribed or lack
sufficient unsubscribed transmission capacity to accommodate the March 2005 RFP:
Idaho to Northwest
. Idaho-Montana
Bridger West
. Idaho-Sierra
Path C
Construction of new transmission facilities would be required to increase
the capacity of any of the above constraints. Construction lead times for new
transmission lines on new rights of way, make it impractical to meet the in-service dates
called for in the RFP.
A discussion and descriptions of Idaho Power s transmission constraints
are contained on pages 18-22 of the 2004 IRP. The 2004 IRP is available at the
following link:
http://www. idahopower.com/pdfs/enerqycenter/irp/2004/2004 I RP final. pdf
Additional information and analysis is contained in the attached "FERC
FORM No. 715 PART VI" document. The electronic version of this document has the
following file name: "Perform6.doc
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 6
The response to this request was prepared by Roger Grim, Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 7
REQUEST NO. 23: Please provide cost estimates and a description of
the improvements that would be necessary for Idaho Power to relieve transmission
constraints into its system such that power could be imported from the market as an
alternative to building the Evander Andrews plant. Provide a copy of any studies or
analysis that has been completed.
RESPONSE TO REQUEST NO. 23:
The attached "FERC FORM No. 715 PART VI" document contains cost
estimates and descriptions of improvements. The electronic version of this document
has the following file name: "Perform6.doc
The response to this request was prepared by Roger Grim , Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 8
REQUEST NO. 24: Please describe in detail any transmission system
improvements , upgrades or additions that have recently been made or are planned in
the general vicinity of the proposed Evander Andrews plant that are not contingent upon
or considered a part of the Evander Andrews Plant. Provide a copy of any study or
analysis completed that recommended such improvements , additions or upgrades. For
any upgrades that have recently been completed , please provide records showing the
total costs for the improvements, additions or upgrades.
RESPONSE TO REQUEST NO. 24:
No recent transmission system improvements, upgrades or additions have
been made in the general vicinity of the Evander Andrews plant. Two new transmission
system improvements are planned in conjunction with the improvements required to
interconnect the generator. The improvements are a 230/138 kV transformer
Evander Andrews and the re-conductor of the Evander Andrews-Mountain Home
Junction 138 kv line. These improvements will address pre-existing operational
concerns and as a result will not have their associated costs allocated to the generator
interconnection. These improvements are discussed in the attached Feasibility Study
Report for the proposed Evander Andrews Peaker.
The response to this request was prepared by Roger Grim, Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 9
REQUEST NO. 28: Please provide a copy of all studies or estimates
used to develop the upper limit estimate of $22.8 million to interconnect the project to
the Company s transmission system. Has the study (referred to on page 5 of the
Application) been completed to define the cost of constructing transmission and
substation facilities required to interconnect the project with the Company
transmission system? If so, please provide a copy of the study. If the study has not yet
been completed , when is completion expected?
RESPONSE TO REQUEST NO. 28:
The large generator interconnection study process is segmented into three
studies. The first study in the process is the "Feasibility Study . As the name implies
this study focuses on the question
, "
Is it feasible to interconnect the generator?". During
this study, reasonable interconnection alternatives are evaluated using powerflow
analysis and those interconnection alternatives which provide acceptable performance
have high level cost estimates developed. The Feasibility Study for a third unit at the
Evander Andrews location was completed in August of 2005 and is attached. The initial
high level cost estimates in the feasibility study totaled $21.8 million for interconnecting
the third unit at Evander Andrews. Subsequent review determined an additional
million of communications equipment would be required.
The next phase of studies is referred to as the "System Impact Study
During the system impact study, transient stability analysis and detailed short circuit
analysis is performed to further assess the performance of the proposed interconnection
alternative. The System Impact Study for the Evander Andrews project is currently
underway.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 10
The third phase of studies is referred to as the "Facility Study . The facility
study starts the detailed design phase of the project and includes detailed construction
estimates. The facility phase of the project can begin after competion of the system
impact study and upon receiving authorization from the customer.
The response to this request was prepared by Roger Grim , Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 11
REQUEST NO. 47: Please explain why the estimated transmission costs
for the Evander Andrews plant are expected to be approximately double the
transmission costs for the Bennett Mountain project when the locations of the two plants
are only a few miles apart.
RESPONSE TO REQUEST NO. 47:
Prior to the addition of the Bennett Mountain project , the Midpoint West
transmission constraint had sufficient uncommitted transmission capacity to transmit the
output of the Bennett Mountain plant to Boise. The transmission improvements required
to interconnect the Bennett Mountain plant to the transmission grid , were essentially a
230 kV line from the plant location to the closest existing bundled 230 kV line(approx. 4
miles) and a substation to interconnect the transmission lines. Prior to the addition of
the third unit at Evander Andrews , insufficient uncommitted Midpoint West transmission
capacity remained to transmit the output of the third unit at Evander Andrews to Boise.
As a result, a new transmission line was required from the Mountain Home area to
Boise, to provide the additional transmission capacity required to interconnect the third
unit at Evander Andrews.
The response to this request was prepared by Roger Grim , Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline, Senior
Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 12
REQUEST NO. 72: Please elaborate on the highlighted portion of the
following statement from page 17, lines 2-6 of Said's direct testimony: "Although the
transmission system will require additional investment in order to integrate the Project
those improvements will provide capacity during all seasons and improve reliability of
the Company s transmission system." Quantify, if possible, seasonal increases in
transmission capacity and improvements in reliability.
RESPONSE TO REQUEST NO. 72:
The third unit at Evander Andrews is expected to run , for the most part
during the summer and winter peak periods of low-hydro years. The additional
transmission capacity associated with the required transmission improvements will exist
during all hours of all seasons. During those hours that the third unit at Evander
Andrews is not running, the additional transmission capacity is available for other uses
and their associated benefits.
Presently there are three 230 kV transmission lines making up the
Midpoint West transmission system and they all terminate in the vicinity of Boise Bench
substation. The addition of the transmission improvements associated with the Evander
Andrews project will create a fourth 230 kV transmission line from the Mountain Home
area to the Boise area. The addition of a fourth 230 kV line will increase the
redundancy and resulting reliability of the transmission system. Further reliability
improvements are gained by terminating the new line at Mora Substation; a remote
location other than Boise Bench.
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 13
The response to this request was prepared by Roger Grim, Engineer
System Planning, Idaho Power Company, in consultation with Barton L. Kline , Senior
Attorney, Idaho Power Company.
+tA.
DATED at Boise, Idaho, this (0 -day of July 2006.
~utJ
BART N L. KLINE
Attorney for Idaho Power Company
---
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 14
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this day of July, 2006, I served a true and
correct copy of the within and foregoing IDAHO POWER COMPANY'S RESPONSE TO
THE FIRST PRODUCTION REQUEST OF COMMISSION STAFF upon the following
named parties by the method indicated below, and addressed to the following:
Commission Staff Hand Delivered
Donovan Walker US. Mail
Deputy Attorney General Overnight Mail
Idaho Public Utilities Commission FAX
472 W. Washington (83702)Email: Donovan.walker(g)puc.idaho.gov
O. Box 83720
Boise, Idaho 83720-0074
Industrial Customers of Idaho Power Hand Delivered
Peter 1. Richardson, Esq.US. Mail
Richardson & O'Leary Overnight Mail
515 N. 27th Street FAX
O. Box 7218 Email: peter(g)richardsonandoleary.com
Boise, Idaho 83702
Don Reading
Ben Johnson Associates Hand Delivered
6070 Hill Road US. Mail
Boise, Idaho 83702 Overnight Mail
FAX
Email: dreading(g)mindspring.com
Mountain View Power, Inc.Hand Delivered
Ronald L. Williams US. Mail
Williams Bradbury, P.Overnight Mail
O. Box 2128 FAX
Boise, Idaho 83701 Email: ron (g)williamsbradbury.com
Robert D. Looper, President Hand Delivered
Mountain View Power, Inc.US. Mail
1015 W. Hays Street Overnight Mail
Boise, Idaho 83702 FAX
Email: rlooper(g)spellc.com
~~-
Barton . KlIne
CERTIFICATE OF SERVICE , Page
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RES PO N S E
REQUEST NO. 22
IDAHO POWER COMPANY
FERC FORM No. 715
PART VI
PERFORMANCE EV ALUA TION
Enclosed
Idaho Power Company s statement regarding performance evaluation is enclosed.
Idaho Power Company s performance evaluation statement plus the WECC 2006
Path Rating Catalog and other documents submitted by WECC constitute Idaho
Power Company s complete response to FERC for Part VI.
Contact Person:
Mailing Address:
Mark D. Hanson
O. Box 70
Boise, Idaho 83707-0070
mhanson (g)idahopower.com
208-388-2253
208-388-6647
E- mail
Telephone Number:
Facsimile Number:
FERC Form No. 715 2006 Filing
Part VI: Performance Evaluation
Evaluation of Transmission System Performance
The WECC Path Rating Catalog identifies existing transmission path constraints in the
Idaho Power System. The Catalog specifies known limits as well as the conditions when
the limits occur. In addition, existing perfonnance is described and stability limitations
are identified.
The need to increase transmission transfer capacity in the future will be driven by the
need to integrate new generation resources, new requests for finn transmission capacity,
or intemalload growth. The following paragraphs discuss opportunities to increase
transfer capacity for specific transmission paths. This reflects the most current planning
and is subject to change as new infonnation becomes available.
Other documents that may be helpful in studying future developments include the
Department of Energy s Fonn EIA-411 and WECC's Ten-Year Coordinated Plan
Summary 2005-2015.
Idaho to Northwest
The limits of the Idaho to Northwest transmission path are described in the Path Rating
Catalog (see Path #14). The present interconnection between Idaho Power and the
Northwest consists of one 500 kV , three 230 kV, and one 115 kV lines.
East to West: The simultaneous east to west transfer capacity is 2400 MW.
West to East: The present simultaneous west to east transfer capacity from the
Northwest is 1200 MW. However, operating restrictions on the Brownlee East
and Oxbow North paths (see corresponding sections for discussion) may prevent
full utilization of this capacity. Restrictions are reached during simultaneous
Hells Canyon Complex generation with imports from the Northwest.
Brownlee East
The Brownlee East transfer path is described in the Path Rating Catalog (see Path #55)
and has an accepted rating of 1850 MW.
Oxbow North
This transfer path is comprised of the Brownlee-Hells Canyon 230 kV and Oxbow-Lolo
230 kV lines (flows are metered at Hells Canyon and Imnaha). The Oxbow North
simultaneous nomogram limit is defined by the emergency thennal capacity of either the
Brownlee-Hells Canyon or Oxbow-Lolo 230 kV transmission line, following the loss of
the other 230 kV line. Limits are reached during simultaneous heavy Hells Canyon
Complex generation and heavy import conditions which typically occur during the spring
and early summer with above average hydro conditions in the Northwest. This path does
not restrict east to west transfers from Idaho to the Northwest.
FERC Form No. 715 2006 Filing
Part VI: Performance Evaluation
The study conditions used to determine the Oxbow North transfer capacity were high
Northwest to Idaho transfers on the Oxbow-Lolo and Hells Canyon-Walla Walla 230 kV
lines simultaneous with high generation at the Hells Canyon plant.
Remedial actions are required for the loss of the Brownlee-Hells Canyon 230 kV line
during high flow conditions North of Oxbow. Generator unit tripping is required at Hells
Canyon under these conditions to maintain dynamic stability of the remaining Hells
Canyon units.
Simultaneous loss of the Brownlee-Hells Canyon and the Oxbow-Lolo 230 kV circuits
limits the ability to fully utiltize the 1200 MW import capability under high Hells Canyon
Complex generation. Additional facilities including new/uprated lines (a new 230 kV
circuit from the Hells Canyon/Imnaha area and increasing the thermal rating of the
existing Hells Canyon-Brownlee 230 kV line) and additional flow control measures (a
phase shifter) will be required to fully resolve this limitation.
Long Term ATC across the Northwest-Idaho and Brownlee East cutplanes is fully
subscribed West-to-East. Idaho Power has considered six conceptual West-to-Eeast
upgrades in the past to the Northwest-Idaho and Brownlee East cutplanes. These are:
Project Voltage Capacity Cost
West-East (in 2000 $)
McNary-Brownlee 230 k V 100 MW $122 000 000
NW-
Lower Monumental-Brownlee 500 kV 100 MW $227 000,000
NW-
McN ary- Brownlee-Boise Bench-Midpoint 345 kV 475 MW $307 000 000
NW-ID/BE
Lower Monumental-Melba 500 kV 575 MW $361 000 000
NW-ID/BE
Lower Monumental- Melba-Midpoint 500 kV 600 MW $483 000 000
NW - ID/BE
Lower Monumental-Melba-Midpoint-Borah 500 kV 600 MW $501 000 000
NW -ID/BE
Idaho-Sierra
The constraints for this transmission path are the Sierra import and export limits as
explained in the Path Rating Catalog (see Path #16). With the completion of the Alturas
project between Sierra and the Northwest and the Falcon-Gonder 345 kV project internal
to Sierra s system, there is now more opportunity to fully utilize the transfer capabilities
on the Idaho-Sierra path.
FERC Form No. 715 2006 Filing
Part VI: Performance Evaluation
Borah West
The West of Borah transfer path is specified in the Path Rating Catalog (see Path #17)
and has an existing East to West rating of 2307 MW.
To accommodate additional transmission requests, the Borah West transfer capacity is
being increased. The Borah West up rate project, which is currently underway, will
increase the Borah West transmission capacity an additional 250 MW from 2307 MW to
2557 MW and has a proposed in-service date of May 2007. The major component of this
project is to rebuild the American Falls-Adelaide and Adelaide-Hunt 138 kV lines to
230 kV. The Borah West up rate project facilities for the plan of service for an additional
250 MW increase in transfer capacity are listed below:
Brady-Am Falls 138 kV line, Re-conductor 0.4 mile, single 1272 kcmil ACSR
Borah-Hunt 230 kV line, Rebuild 70.0 miles of 138 kV to 230 kV , single 1590
kcmil ACSR
Borah 345 kV, 175 Mvar Shunt Capacitor
Midpoint 345 kV, 175 Mvar Shunt Capacitor
The Borah West up rate project has completed the WECC three phase path rating process
and was granted Phase III status in March of 2003.
Idaho - Montana
The transfer capacity for the Idaho - Montana path is specified in the Path Rating Catalog
(see Path #18). The thermal capacity of the Anaconda-Antelope 230kV line is 462MW;
however, the transfer capacity of this line is steady-state voltage limited to 250MW.
Idaho Power has considered three conceptual upgrades in the past to the Idaho-Montana
cutplanes. These are:
Project Voltage Capacity Cost
North-South (in 2000 $)
Mill Creek-Antelope 161 kV 100 MW $105 000 000
Garrison-Mill Creek-Antelope-Brady 230 kV 250 MW $150 000 000
Garrison- Borah- Midpoint 500 kV 800 MW $347 000 000
Brid2er West
The Bridger West transfer path is specified in the Path Rating Catalog (see Path #19) and
has an existing East to West rating of 2200 MW. To increase the Bridger West transfer
capacity beyond 2200 MW to approximately 2400 MW will require the replacement of
the Borah and Kinport series capacitor banks, and additional shunt reactive support to be
added in the Bridger system.
FERC Form No. 715 2006 Filing
Part VI: Performance Evaluation
Midpoint West
The Midpoint West transfer path is comprised of the Midpoint-Dram 230kV line, the
Midpoint-Rattlesnake #2230 kV line, the Midpoint-Boise Bench #3 230kV line, and the
Upper Salmon - Mt Home Jet and the Lower Malad - Mt Home Jet 138 kV lines. The
east to west transfer limit is approximately 11O0MW at the Midpoint end.
The west to east transfer limit is approximately 750MW and is based on the N-l rating of
the three 230kV lines and the underlying 138 kV transmission system. Under west to east
flow conditions, the transfer limit was developed with high Northwest to Idaho transfers
resulting from above average hydro conditions, high Hells Canyon Complex generation
and low eastern thennal resources.
With uprating of the Boise Bench-Dram 230 kV line, the west to east transfer limit of
Midpoint West can be increased approximately 150MW.
Future Facility Additions
Idaho Power considered the Southwest Intertie Project (SWIP) to capture the economics
regional diversity more fully, thus making the best use of existing resources and
potentially deferring new generation projects. Idaho Power is no longer pursuing this
project and has granted an option for it to Great Basin Transmission, LLC to develop this
transmission corridor. SWIP can offer significant benefit to the Northwest and Southwest
utilities by enhancing competition and efficiency in the regional bulk power market. The
project is described below.
Southwest Intertie Project: The SWIP is a proposed 500kV transmission
system from Midpoint substation to Crystal substation, a Nevada Power
Company s (NPC) substation located north of Las Vegas, NY. The
proposed bi-directional rating of the line is approximately 1200MW.
SWIP will be approximately 520 miles long and will require one or two
series capacitor stations in addition to tenninations in the Midpoint and
Crystal substations. At Midpoint, SWIP will require a 500/345kV
transfonnation only if the Borah-Midpoint 345 to 500kV upgrade project
is not built.
In addition, to fully develop and utilize the SWIP project, additional
transmission projects will be required to increase the W -E and E- W Idaho
to Northwest transfer capacity.
The SWIP integration with the southern Nevada transmission system is
planned to be at NPC's Crystal substation.
ID AH POWER CO MP ANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 23
See documents attached to
Response to Request No. 22
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 24
LARGE GENERA TOR INTERCONNECTION
FEASIBILITY STUDY REPORT
for the
230 KV INTERCONNECTION OPTION
EV ANDER ANDREWS PROJECT
for
Idaho Power Power Marketing, Interconnection Customer
for connection of
A 200 MW SIMPLE CYCLE GAS TURBINE PEAKING PROJECT
EV ANDER ANDREWS PROJECT
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
August 4, 2005
1.0 Introduction
Idaho Power Power Marketing has contracted with Idaho Power Company (IPC) to perform a
Large Generator Interconnection Feasibility Study for Network Resource Interconnection
Service at 230 kV for the integration of a new 200 MW simple cycle gas turbine peaking
project. The proposed location is the Evander Andrews Project near Mountain Home, Idaho.
This report documents the basis for and the results of this Feasibility Study. It describes the
proposed interconnection alternatives, the study cases used, outage scenarios assumed and
results of all work in the areas of concern.
Summary
The performance of three interconnection alternatives was evaluated to integrate a 200 MW
simple cycle gas turbine, located at Evander Andrews Project, into the Idaho Power System.
Alternative #3 is the recommended alternative.
Alternative #1:
Alternative #2:
Alternati ve #3:
Construct a radial 230 kV interconnection line, from a new 230 kV substation
at Evander Andrews, to the Midpoint-Boise Bench #3 transmission line.
Numerous N-1 contingencies resulted in unacceptable overloads for this
alternative. The additional improvement of a 230/138 kV transformer at
Evander Andrews was evaluated in an unsuccessful attempt to achieve
acceptable performance under N-1 outage conditions.
Construct two new 230 kV transmission lines from Bennett Mountain to
Evander Andrews and Evander Andrews to Rattlesnake. These lines would
complete a 230 kV loop from Rattlesnake to Bennett Mountain to Evander
Andrews and back to Rattlesnake. In addition, the Dram-Midpoint #1 230 kV
line would be looped into Rattlesnake and rebuilt to support bundled 230 kV
conductors west of Rattlesnake. Additional transmission modifications were
also modeled at DRAM substation to make the "Old Midpoint to DRAM #1"
230 kV line bypass the DRAM Substation and terminate at Boise Bench. A
230/138 kV transformer was modeled at Evander Andrews to improve system
performance under N-1 conditions. Alternative #2 has one N-1 outage that
produces an overload that exceeds 115% of continuous rating. In addition
three N-1 contingencies still require curtailments for Alternative #2.
Alternative #2 is an unacceptable alternative due to the N-1 outage that
produces an overload that exceeds 115%. Alternative #2 is anticipated to be
similar in cost to Alternative #3, yet does not perform as well.
Rebuild a de-energized 132 kV transmission line to 230 kV construction
between Bennett Mountain and Mora Substations. This alternative utilizes the
406 line route which passes in the vicinity of Evander Andrews. The west end
of the 230 kV line is assumed to terminate at a new 230 kV Mora Substation
which is folded into the Boise Bench-Caldwell 230 kV line. No 230/138 kV
transformer is modeled to tie the two Mora busses. A 230/138 kV transformer
was modeled at Evander Andrews to improve system performance under N-
conditions. Studies revealed the need to reconductor/rebuild the Evander
Andrews to Mountain Home Junction 138 kV line. With the previously
mentioned additions in-service, two N-l outages produce overloads above
equipment continuous ratings. One overload only requires a 2% reduction in
loading to fall to a level that can be sustained continuously. Opening another
lightly loaded line can mitigate the other overload. The estimated total cost
for this alternative is approximately $26 Million, with approximately $22
Million allocated Idaho Power Power Marketing for the generator
interconnection improvements and the remaining $4 Million allocated to
Idaho Power Delivery to correct existing operational concerns. Following the
execution of either a Large Generator Interconnection Agreement or a
Engineering & Procurement Agreement by Idaho Power Power Marketing,
Idaho Power Company estimates the time required to construct these facilities
is approximately 18-21 months.
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads, and allowance for funds used during construction (AFUDC). A cursory
attempt has been made in this study to characterize each transmission improvement as either
needed to integrate the proposed generator" or "needed to correct existing operational
concerns . The proposed cost allocation is subject to change, as more information is known.
These are cost estimates only and final charges to the customer will be based on the actual
construction costs incurred.
Summary of Interconnection Request
A request was made to Idaho Power Co. by Idaho Power Power Marketing to study the
interconnection of a proposed 200 MW simple cycle gas turbine at the Evander Andrews
Project, near Mountain Home, Idaho, to Idaho Power s transmission system at the 230 kV level
for Network Resource Interconnection Service.
Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with the FERC
Order 2003-, Standard Large Generator Interconnection Procedures, to provide a preliminary
evaluation of the feasibility of the interconnection of the proposed large generating project to
the Idaho Power transmission system. This study will only be concerned with the capabilities
of the Idaho Power system to manage this new resource within the study area of the proposed
interconnection.
Description of Proposed Generating Project
Idaho Power Power Marketing proposes to connect a 200 MW simple cycle gas turbine to the
Idaho Power 230 kV transmission system, at the existing Evander Andrews Power Complex
1862 NW Mashburn RD., Mountain Home, ill 83647. The maximum generating capacity of
the proposed unit is estimated to be 200 MW for both summer and winter temperatures. The
equipment is described as being, a Siemens Westinghouse 501F Econopac. The proposed
commercial operation date is April 1 , 2007.
Description of Existing Transmission Facilities
At the Scoping Meeting for this Interconnection Request, it was agreed that the interconnection
voltage to be studied would be 230 kV. The existing generating units at Evander Andrews Power
Complex utilize the 138 kV transmission grid. No 230 kV transmission is present at Evander
Andrews at this time.
Evander Andrews has four 230 kV lines in relatively close proximity. Three of them run from the
Midpoint Substation(north of Twin Falls, ill) to the east Boise area. The closest is the Midpoint-
DRAM #1 line, which is approximately 4 miles Northeast of Evander Andrews. This line utilizes
single 715.5 MCM conductors and has a continuous rating of 339 MV A. The Rattlesnake-Boise
Bench #2 line is approximately 5 miles Northeast of Evander Andrews and utilizes a 2 conductor
bundle of 715.5 MCM. This line has a continuous rating of 677 MV A. The Midpoint-Boise
Bench #3 line is approximately 7 miles Northeast of Evander Andrews. This line has similar
conductors and the same rating as the Rattlesnake-Boise Bench #2 line. The fourth 230 kV line in
the area is the Rattlesnake-Bennett Mountain line. It is approximately 5 miles to the Southeast of
Evander Andrews. This line utilizes single 1272 MCM conductors and has a continuous rating of
478 MV A.
In addition to the three Midpoint to the east Boise area 230 kV lines previously mentioned, there
are two 138 kV circuits which can carry power from the Mountain Home area to the Boise Area.
They are:
Mountain Home Junction-Lucky Peak-Micron 138 kV Line
Mountain Home Junction-Evander Andrews-Strike-Swan Falls-Bowmont 138 kV
Line
Generators located in the Mountain Home area which are intended to serve load growth in the
Treasure Valley area, will be adding new incremental flows on top of existing committed east-to-
west transactions across the Midpoint West transmission cutplane. This feasibility study will
model 1100 MW of transfers across the Midpoint West cutplane , prior to this proposed generator
addition. For these studies, the flow level of the Midpoint west cutplane is defined as the sum of
the flows on the following lines:
. Midpoint-DRAM #1 230 kV line
. Midpoint-Rattlesnake #2230 kV Line
. Midpoint-Boise Bench #3230 kV Line
Lower Malad-Mountain Home Junction 138 kV Line
Upper Salmon-Mountain Home Junction 138 kV Line
Description of Configurations Studied
Since the most limiting operating conditions are expected during heavy production on the
upper and middle Snake and Boise River hydro plants, with heavy east-west transfers across
the Idaho Power transmission system, the injection of the simple cycle gas turbine s 200 MW
output was inserted into a power flow case that would simulate committed (1100 MW) pre-
contingency flows on the Midpoint West transmission path.
In accordance with the Scoping Meeting for this Feasibility Study Request, three alternatives
were studied, all of which employed a 230 kV interconnection voltage.
Alternative #1 employed a radial 230 kV line to connect the generator to the Midpoint-Boise
Bench #3 transmission line. The line was modeled as being 7.7 miles in length and utilized
1272 MCM single conductor construction. An additional improvement of a 230/138 kV 200
MV A transfonner(duplicate of the Midpoint unit) was explored at Evander Andrews to
improve the perfonnance of this alternative.
Alternative #2 calls for the construction of two new 230 kV transmission lines from Bennett
Mountain to Evander Andrews, and Evander Andrews to Rattlesnake. These lines would
complete a 1272 MCM single conductor 230 kV loop from Rattlesnake to Bennett Mountain to
Evander Andrews and back to Rattlesnake. In addition, the Dram-Midpoint #1 230 kV line
would be looped into Rattlesnake and rebuilt to support a two conductor bundle of 715.5 MCM
conductors west of Rattlesnake. Additional transmission modifications were also modeled
outside of DRAM substation to make the "Old Midpoint to DRAM #1" 230 kV line bypass
the DRAM Substation and tenninate at Boise Bench. The combination of bundled conductors
and folding the #1 line into Rattlesnake Substation necessitated the change to avoid overloads
at DRAM associated with the loss of the DRAM to Boise Bench 230 kV line. A 230/138 kV
200 MV A transfonner(duplicate of the Midpoint unit) was modeled at Evander Andrews to
improve system perfonnance under N-l conditions.
Alternative #3 employed the rebuild of a de-energized 132 kV transmission line to 230 kV
bundled 795 MCM construction between Bennett Mountain and Mora Substations. This
alternative utilizes the 406 line route (originally was the Upper Salmon to Caldwell line) which
passes in the vicinity of Evander Andrews. The west end of this new 230 kV line is assumed
to tenninate at a new 230 kV Mora Substation , which is folded into the Boise Bench-Caldwell
230 kV line. No 230/138 kV transfonner is modeled to tie the two Mora busses. A 230/138
kV 200 MV A transfonner(duplicate of the Midpoint unit) was modeled at Evander Andrews to
improve system perfonnance under N-l conditions. Studies also revealed the need to
reconductor/rebuild the Evander Andrews to Mountain Home Junction 138 kV line , with this
alternative.
Post-transient Study Results
This Interconnection Feasibility Study Report is for Network Resource Interconnection Service
at 230 kV , for a 200 MW simple cycle gas turbine at the Evander Andrews Power Project.
System transfers across the Midpoint West cutplane are modeled at 1100 MW prior to the
proposed transmission improvements or the proposed generator producing any power. Hydro
generation production for the Boise & Snake plants , were modeled at heavy, but realistic
levels. Ouput levels for the existing peakers at Evander Andrews and Bennett Mountain were
varied over their operating ranges as appropriate. N-O and N-l outage perfonnance for the
existing system are recorded. As agreed in the Scoping Meeting, three alternatives were
evaluated. For each alternative, the new generator s output was taken to its maximum level of
200 MW and system conditions recorded for both N-O and N-l outages.
Existing System
The following one line diagram depicts the existing system with no outages.
Mid oint West = 1100 MW
u..""";~.: w'
~~'~',~ \:':;,""" ""'""'" """,""'"
fA-.i~~5::r-;C .
""""'L
~""
~~1~.~1~.
Existing System - No Outages
Figure 1
For the existing system, seven N-l outages produce overloads that exceed the continuous
rating of elements of the transmission system. The N-s that produce overloads with the
existing system are included in Appendix B , Figures 9 - 15.
Alternati ve # 1
The following one line diagram depicts the system with Alternative #1 added, full output of the
generator, and with no outages.
BOWMONT1.01,"
----~"
SWANFALL S1lUKE
,%"
"", 1,02," 1.03,"I;W
~~'"",' '
il'::SWNFl PO r'~
"""
1.02," , "1SWANFALL. 1.00," 9.0MW(i!:iJ/ O.B Mm
\.'
90MWBM",
Mid oint West = 1063 MW
::;;g~:-:.,
"iIt,
BURNS
, ." /,
I.O""
Alternative #1 - No Outages
Figure 2
Alternative #1 has multiple N-l outages that produce overloads that exceed 115% of
continuous ratings. Some of the resulting overloads are reduced with the addition of the
Evander Andrews 230/138 kV trans fonner, and others are increased. The largest overloads are
produced by the Lockman Butte to Boise Bench #3230 kV line outage. The following one
line depicts a 128 % loading on the Mountain Home Junction to Lucky Peak 138 kV line
without the Evander Andrews 230/138 kV transfonner.
SWNFlPO ,1.01 '" SWANFALLOO'" 9,OMW:r:104M",~) 9.0MW104M",
Midpoint West = 910 MW
Alternative #1- Lockman Butte-Boise Bench #3 230 kV Outage
Without the Evander Andrews 230/138 k V Transformer
Figure 3
Adding the Evander Andrews 230/138 kV Transfonner to the above outage, produces a 172%
loading on the Mountain Home Junction to Lucky Peak 138 kV line.
With the Evander Andrews 230/138 kV transformer in-service, only one other N-1 outage
produces overloads that exceed 115% loading and are also greater than existing system
overloads for the same N-l. That N-1 is loss of the Rattlesnake to Boise Bench #2230 kV
line.
Without the Evander Andrews 230/138 kV transfonner in-service , four other N-1 outages
produces overloads that exceed 115% loading and are also greater than existing system
overloads for the same N-l. They are:
Rattlesnake - Boise Bench #2230 kV Line outage
Midpoint - Rattlesnake #2230 kV line outage
Evander Andrews - Strike 138 kV line outage
Strike - Bowmont 138 kV line outage
Several other N-1 outages result in overloads below 115% that would require curtailments
following the outage to get down to loadings that can be sustained continuously. In some
cases , lowering the output of the proposed generator helps to lower the overload, but in one
case (Lucky Peak - Micron 138 kV line outage), the overload increases as the proposed
generators output is lowered.
Alternative #1 is an unacceptable alternative, due to two N-1 outages which produce overloads
that exceed 115% of continuous ratings. The Network Rating for Alternative #1 is 0 MW.
Alternati ve #2
The following one line diagram depicts the system with Alternative #2 added, full output of the
generator, and with no outages.
Midpoint West = 1083
Alternative #2 - No Outages
Figure 4
The addition of the Evander Andrews 230/138 kV transformer improves the performance of
Alternative #2 for most N-l outages , but not all. Alternative #2 has one N-l outage that
produces an overload that exceeds 115% of continuous rating and is also greater than existing
system overloads for the same N-l. The outage is the Rattlesnake to Boise Bench #1 230 kV
line. The following one line diagram depicts this outage at 200 MW of output on the proposed
unit.
Midpoint West = 1028
Alternative #2 - Rattlesnake to Boise Bench #1
Line Outage
(g)
200MW of Output
Figure 5
The output of the new unit needs to be restricted to approximately 163 MW to limit the
overload to 115% on the Mountain Home Junction to Lucky Peak 138 kV line for this N-
outage. For this reason, this alternative does not provide adequate performance for a Network
Resource Rating of 200 MW. The following one line diagram depicts this condition.
Alternative #2 - Rattlesnake to Boise Bench
Line Outage (g) 163 MW of Output
Figure 6
Curtailments are required for all three N -1 outages of the 230 k V lines from the Mountain
Home area into Boise Bench. Loss of the Rattlesnake to Boise Bench #1 or #2 lines require
the proposed unit's output to be lowered to approximately 67 MW to reduce overloads to
100% of the continuous rating or a level that the overload is no worse than it is for the existing
system with the same N-1 outage. These contingencies and resulting system perfonnance
detennines the Network Resource Rating to be 67 MW for Alternative #2. The loss of the
Midpoint to Boise Bench #3230 kV line requires a curtailment to lower a 118% overload of
the series capacitors on the Midpoint to Rattlesnake #2230 kV line. This alternative does not
pennit the overload to be reduced by lowering the output of the proposed unit. Lowering the
output of proposed unit will increase the overload on the series capacitors in question. Other
generators would have to be curtailed to solve this overload scenario.
Alternative #2 is an unacceptable alternative for the proposed unit at 200 MW for Network
Resource Interconnection Service, due to the N-1 outage that produces overloads that exceed
115% of continuous ratings. The Network Resource Rating for Alternative #2 is 67 MW.
Alternative #2 is also believed to very similar in cost to Alternative #3 , yet it s perfonnance is
much more problematic than Alternative #3.
Alternative #3
The following one line diagram depicts the system with Alternative #3 added, full output of the
generator, and with no outages.
Mld olnt West = 1103
~... ., ~)
It ."':'-.~' I( MI
':;':
"9
' .
"m... .
, '
;~"1 V MI""""
'Y""MICRON
",\ """""'. ".
I!
"'"'"
'" _en
""" """"'"
~ii .f!i".
"" rP
' ... (
~2"TMTcr (I', "'\'rir;;:11 Wit
"""
UD... ~
\1:"::C':::
"'" ,'"
~;:B'
.""
':iit"
,;:;;
~.J
) "1m'.
.~""'"
U"
'-..;
7t--
g~
l!~I.-;~~~;;'
"'"
"'.i:'. (:;::" 6'1
;; "'"" ,. .
'tJF,..~"'
oj
"',",. ,=/'(:.:\ ""'
t::'
-... "'~ ..;""
t::' I""'" M""" '";?~L\
:' ~ '.,. ,.
m... "
' '...
'99... ON",,"-1i-,
:l1--(~) 5T~"
, .
"'i"'"", 'I'~....tP,....
..
tP 1\1:'.
Alternative #3 - No Outages
Figure 7
The addition of the Evander Andrews 230/138 kV transfonner improves the perfonnance of
Alternati ve #3 , for all but one of the N -1 outages. Alternative #3 has no N -1 outages that
produce overloads that exceed 115% of continuous ratings.
Two N-1 outages result in overloads below 115% and at a level that the overload is greater
than it is for the existing system with the same N-l outage. The loss of the Midpoint to Boise
Bench #3 230 kV line results in a 112% loading on the series capacitor of the Midpoint to
Rattlesnake #2230 kV line. This series capacitor is capable of 110% loading continuously, so
a 2% reduction in flow is required. Lowering generation in the Mountain Home area results in
increased flow on the series capacitor bank, so transfers across the Midpoint West cutplane
will need to be reduced to correct this overload, as well as prepare for the next contingency.
The second N-1 outage that results in an overload below 115%, is the Evander Andrews to
Mora 230 kV line. This N-1 outage results in a 106% loading on the Mountain Home Junction
to Lucky Peak 138 kV line. This overload can be managed by opening the Evander Andrews
to Mountain Home Junction 138 kV line.
Alternative #3 changes the characteristics of the interconnected network enough to create the
need to reconductor/rebuild the Evander Andrews to Mountain Home Junction 138 kV line.
For the N-1 outage of the Lucky Peak to Micron 138 kV line, the Evander Andrews to
Mountain Home Junction 138 kV line loads to 109% of its rating with all the peaking
generation in the Mountain Home area at full output. If the output of the peaking generation in
10-
the Mountain Home area is reduced, the overload increases in magnitude. The following one
line diagram depicts the Lucky Peak to Micron 138 kV line outage with all the Mountain
Home area peaking generation offline.
Midpoint West = 1157 MW
""'-00'
..
un.. If~::
\ '"- "
""",me,;-2; ,\/1 0,
"'"":'.- .
j;~L
,.:,'
~";W"'
~~~ """
t:P l Ii~;
"" """""" ,
.:;J
if~'--8-III-"'!'!!ff;1'- ,,1'11\, m",
,..~ '; ..~
~..;: j:tg!~.
~!~.(;)' '
'W'"
~:;~. '
,om;u"" .
Alternative #3 - Luck Peak to Micron 138 kV Line Outage
With Peakers Off-line
Figure 8
Alternative #3 is the recommended alternative for the proposed unit at 200 MW for Network
Resource Interconnection Service.
Cost Allocation of Proposed Improvements
Alternative #3 contains the following five construction components:
Bennett Mountain to Evander Andrews 230 kV line and tenninals
Evander Andrews to Mora 230 kV line and tenninals
230 kV generator connection tenninal at Evander Andrews
Evander Andrews 230/138 kV transfonner and terminals
Reconductor/rebuild of the Evander Andrews to Mountain Home Junction 138
kV line
A cursory attempt has been made in this study to characterize each transmission improvement
as either "needed to integrate the proposed generator" or "needed to correct existing
operational concerns . The costs associated with those improvements believed to be "needed
to integrate the proposed generator" are allocated to the generator interconnection. The costs
associated with those improvements believed to be "needed to correct existing operational
concerns " are allocated to IPCo Delivery.
11-
Approximate estimated costs allocated to the generator interconnection are:
$ 4.1 Million - Bennett Mountain to Evander Andrews 230 kV line and terminals
$17.3 Million - Evander Andrews to Mora 230 kV line and terminals
$ 0.4 Million - 230 kV generator connection terminal at Evander Andrews
$21.8 Million - Total estimated generator interconnection cost
Approximate estimated costs allocated to the IPCo Delivery are:
$2.1 Million
$1.7 Million
$3.8 Million
- Evander Andrews 230/138 kV transformer and terminals
- Evander Andrews to Mountain Home Junction 138 kV line rebuild
- Total estimated allocation to IPCo Delivery
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads , and allowance for funds used during construction (AFUDC). The proposed
cost allocation is subject to change, as more information is known. These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred.
10.Short Circuit Study Results
Preliminary short circuit study results indicate the surrounding circuit breakers are believed to
be able to accommodate the increased fault duty. No circuit breaker replacements are
anticipated at this time.
11.Conclusions
The feasibility of interconnecting a 200 MW simple cycle gas turbine at Evander Andrews Power
Complex to Idaho Power s 230 kV transmission system was studied. Three interconnection
alternatives were evaluated. Both Alternatives #1 & #2 were found to be unacceptable alternatives
due to transmission system loadings that exceeded 115% for N-l outages. Alternative #3 was
found to be an acceptable interconnection alternative. While Alternative #3 does require minimal
redispatch/transmission switching for two N-l outages, they are minor in nature and deemed
acceptable for this feasibility study. The estimated total cost of the transmission improvements
associated with Alternative #3 is approximately $26 Million. At this time it is believed that
approximately $22 Million of these estimated costs should be allocated to the generator
interconnection.
12-
APPENDIX A
1.0 Method of Study
The study methodology inserts the proposed generator up to the maximum requested output of
200 MW into the selected WECC power flow case and then, using the PowerWorId Simulator
powerflow program, examines the impacts of the new resource on Idaho Power s transmission
system (lines , transformers, etc.) within the study area under various operating/outage
scenarios. The WECC and Idaho Power reliability criteria and Idaho Power operating
procedures were used to determine the acceptability of the alternatives considered. The WECC
case is a recent cases modified to simulate stressed but reasonable pre-contingency energy
transfers utilizing the IPC system.
Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine the
acceptability of the alternatives:
Loadings on transmission lines and transformers should not exceed 115% of the
continuous rating, immediately flowing any N-1 outage. Loading on the Midpoint 230
kV series capacitors should not exceed 135% of the continuous rating, immediately
flowing any N-1 outage. These loadings levels of 115% on transmission lines and
transformers and 135% on Midpoint series capacitors correspond to IPCo s 30 minute
emergency equipment ratings. Any loadings immediately following an N-1 outage
less than the 30 minute emergency rating is acceptable.
Loadings which are less than the 30 minute emergency equipment ratings, but greater
than the equipment continuous ratings , must be reduced to the continuous ratings by
generation curtailments, re-dispatch, or some other operating procedure. Any remedial
action schemes(RAS) or other transmission switching, must be judged to be reasonable
before the alternatives performance can be deemed acceptable.
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or
as determined by Idaho Power. Less than or equal to 100% of continuous rating for
transmission lines and transformers is acceptable. Less than or equal to 110% of
continuous rating for the Midpoint 230 kV series capacitors is acceptable.
Transmission voltages, under normal operating conditions, are maintained within plus
or minus 5% (0.05 per unit) of nominal. Therefore , voltages greater than or equal to
95 pu voltage and less than or equal to 1.05 pu voltage are acceptable.
The stable operation of the transmission system requires an adequate supply of volt-
amperes reactive (V ARs) to maintain a stable voltage profile under both steady-state
and dynamic system conditions. An inadequate supply of V ARs will result in voltage
13-
decay or even collapse under the worst conditions. Idaho Power designs its system to
integrate Network Resources at full capability during specified outage conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future
ratings are outside the scope of this study. Future transmission changes may, however, affect
current facility ratings used in the study.
14-
APPENDIX B
1.0 N -1 Outages That Produce Overloads On The Existing System
The following one line diagrams depict system perfonnance following the seven N-l outages
that produce overloads which exceed the continuous rating of facilities. Figure 1 on page 5
depicts the operation of the existing system with no outages. The combination of heavy hydro
and peaker generation in the Mountain Home area, and 1100 MW east to west transfers on
Midpoint West, results in the Mountain Home Junction to Lucky Peak and Lucky Peak to
Micron 138 kV lines being loaded to 98% & 99% respectively, prior to any outages.
80""'",m,.
Midpoint West = 981
~~"
'fffF',.,"""'"
~~~'" ,.
"...,~1-4:: ,.~i).
""~'.' \""""'" '
50"""" 0.99,.
"""'""" """
fa.-"~
"'" ,"'"
~:rr-;D~U/"t""~L
9...,c;';)"".
c;';)1~.
""""N
c;::J,~""
(11, ;8
~~;;: .;,';~:
"tH:'!/toYrtf'"
C:J
.". m" """"N
";;;.'""'" ."'"
Existing System - Midpoint to Boise Bench #3 230 kV Outage
Figure 9
15-
Mid oint West = 951
I""
""""""'",
9N"""'-C,,\ '" "" ",,'i'--!i1"
'---'
'J,
:',.","'
t8-1
.1./
..9) 9N"""'-
~'"
'j:01~.~1~.
""""N
*8
~':::.,...(?g~
"""'11
li~fi \;J
,-r&;'?
/;~')"""\; ,~~
(?:J"f~ '~'E~f::~,
Ii"
'J"'"W"'"
Existing System - Rattlesnake to Boise Bench #2 230 kV Outage
Figure 10
Midpoint West = 997
"""""",,,
"f"
f"" tfJ
f"" tfJ ::~5
""""'" D,
,..
9N"""'-
"""
ia-.
""""
'1'
~:; ~.;,)\ ,
9N""","
~'"
~~1~.~1~.
"""""
c;::J:~ ::.,
,) c.
~'\~ ,',:':"./ :,.\~.
t~'!f! 7-"
\'::)
"fM',::' ;0 i:'
::;;'"'"' """
Existing System - Midpoint to Rattlesnake #2230 kV Outage
Figure 11
16-
~~' ,
w= "
1:I;'I tP
""'"""" .;, ",),"" ((' , ,...,..... '-""" """""-
"1i' ;t';,~
"" '" . '""'"
';:;:;'i ~.i~:
J..~~:l-~"" 'j:(gm:~1W.
Existing System - Midpoint to DRAM #1230 kV Outage
Figure 12
;L.
OlntWest = 1085 MW
.;..;
C:? g~--4/W" i ..;
?,"
i ""
. ...;.,""""" \:;' . .:~.
"'ON;
""'"
Existing System - CJ Strike to Bowmont 138 kV Outage
Figure 13
17-
Midpoint West 1072 MW
"""..."""
~~ ~3 ~'"
~..;: ~~H1~'~1WN
Existing System - Lucky Peak to Micron 138 k V Outage
Figure 14
Mid oint West = 1094 MW
,;,
"tlf':, IOC"""f~~~
"""
"""~.I-"
-(''"" """"" ""'"
SWAN'AU.
1i-~~::
:,"~:~
"'W..sw"""
~,,;:
~!WN~!WN
;~J ""-0011""'
"""""
iM.'" 101",'0" ,\\;:;;~JL~M," Tmcr ..
,?,
~J'# T(I~F01'f,WN
:):';"""";"
"""UN
~ ";"" ,"" ~.~,::;,
3.~':::;:'
'" .
2? 8~
11Iff!
-!,./\':'("""
"IM'~
~:~:;~...J
I:::)
~~...,
",'XU ""N
,,:'""'"
c;J ~~ BUR""
""'" """
'" c;J ~~
MICro""
"""
Existing System - Evander Andrews to CJ Strike 138 kV Outage
Figure 15
18-
ID AH POWER CO MP ANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 28
See documents attached to
Response to Request No. 28